KURTEN SWITCH PROJECT (BRYAN/ COLLEGE STATION AREA UPGRADES) Technical Advisory Committee December 1, 2005 Transmission Services

Goals and Objectives Maintain reliable service to customers –ERCOT Planning Criteria –NERC Planning Standards and Guidelines –Good Utility Practice Support load growth in Bryan/ College Station area Support increased imports into area as local generation suspends operations Current planned projects meet the short-term needs for the area, but a long-term solution is required by 2009

Scope of Project Construct a 345-kV substation, Kurten Switch, in one circuit of the Twin Oak-Gibbons Creek 345-kV double circuit lines with a 345/138- kV 600-MVA autotransformer Construct a double circuit 138-kV line from Kurten Switch through Kurten into Tabor; break the Dansby to Steephollow 138-kV line so that the portion to Steephollow ties into Tabor and the portion to Dansby ties into Kurten Complete the Booneville to College Station Switch 138-kV upgrade Convert Booneville to Tabor to 138-kV operation Move the 69-kV line from Sutton to terminate at Tabor In-service date is spring 2009

Bryan and College Station area

Kurten Switch Configuration

Estimated Project Cost 345/138 kV Kurten Switch Project and Associated Upgrades –$16.6 M estimate –Annual Carrying Cost = $ 2.7 M Based upon 16.5% annual carrying charge rate These are functional estimates based upon typical project costs, which are subject to change and should not be presumed to capture the exact amount or timing of projected capital expenditures.

Open Process Regional Planning Group analysis and input –Study updates presented at North Regional Planning Group open meetings on November 16, 2004 and May 11, 2005 –Project sent to North and South Regional Planning Groups October 17, 2005 for comment –All comments received were in favor of the project ERCOT independent assessment –ERCOT Staff supports this project –Notice sent November 16, 2005 to RPG’s

Independent Analysis ERCOT Staff has performed independent analysis using in-house expertise, models and software tools of these projects –Thermal studies Using Siemens PTI PSS/E & MUST –Voltage Stability analysis Using Powertech VSAT –Production Cost analysis Using UPLAN

Bryan and College Station area Brazos County Load – 507 MW in 2003 –Growth to ~600 MW in 2010 (2.5%/yr) BTU has submitted Notice of Suspension of Operations to mothball Atkins 3, 4, 5 & 6 June 1, 2006 No new generation development in area NERC Category C contingency caused local blackout April 15, 2003

Recommendation Request TAC support for the Kurten Switch project

Questions Due to its very nature, transmission planning is a continuous process and is constantly changing due to the addition (or elimination) of plans for new generation, transmission facilities, equipment, or loads. Benefits of good planning are not realized until transmission projects are completed and placed in service.

Options Considered to Maintain Reliability Option 1 - Construct an approximately 100-mile 345-kV line from TNP One to Salem. Install two 345/138-kV autotransformers in the Bryan and College Station area – one at Dansby and one further south, possibly at Snook This alternative was the most significant studied since it involves approximately 100 miles of new 345-kV right of way (ROW). Looking at past history of similar 345-kV projects, it can be concluded that this project would cost well over $100 million and may not be completed until after Initial economic analysis indicated very little possible production cost savings and it did not solve the reliability needs better than the selected option. Not Viable

Options Considered to Maintain Reliability Option 2 - Construct an approximately 50-mile radial 345-kV line from Sandow to Dansby. Install one 345/138-kV autotransformer at Dansby This option also represents a significant project in terms of new ROW, cost, and construction time. Initial studies indicate that this line did very little to prevent post-contingency overloads in the Bryan and College Station area. Not Viable

Options Considered to Maintain Reliability Option 3 - Replace the three 345/138-kV autotransformers at Gibbons Creek with three new autotransformers with ratings of 600 MVA each. Additionally, reconductor the Gibbons Creek to Greens Prairie 138-kV line to have a Rate B of 386 MVA. Rebuild Greens Prairie to Bryan South to Bryan South Switch 138-kV line to have a Rate B of 422 MVA. Reconductor Gibbons Creek to East 138-kV line to have a Rate B of 386 MVA. Complete the Booneville to College Station Switch 138-kV upgrade. Convert Booneville to Tabor to 138-kV operation. Move the 69-kV line from Sutton to terminate at Tabor. At a cost of $23,690,000 this options cost more than the selected option and did not provide any additional production cost savings. Additionally, it did not provide the flexibility of the selected option and construction clearances would be difficult to obtain. Rejected

Options Considered to Maintain Reliability Option 4 - Construct a 345-kV bus at Keith Switch with a 600-MVA autotransformer. Additionally, reconductor the Gibbons Creek to Greens Prairie 138-kV line to have a Rate B of 386 MVA. Rebuild Greens Prairie to Bryan South to Bryan South Switch 138-kV line to have a Rate B of 422 MVA. Reconductor Gibbons Creek to East 138-kV line to have a Rate B of 386 MVA. Complete the Booneville to College Station Switch 138-kV upgrade. Convert Booneville to Tabor to 138-kV operation. Move the 69-kV line from Sutton to terminate at Tabor. At a cost of $19,410,000 this option cost more than the selected option and did not provide any additional production cost savings. Additionally, it did not provide the flexibility of the selected option and construction clearances would be difficult to obtain. Rejected

Options Considered to Maintain Reliability Option 5 - Construct a new 345-kV switch station approximately 8 miles north and west of Gibbons Creek on the Gibbons Creek to Twin Oak double circuit 345-kV lines with a 600-MVA autotransformer and construct a new, approximately 11-mile, 138- kV line from this switch station to Steephollow substation. This option had approximately the same affect that Option 4 had in terms of relieving post-contingency overloads, but would cost significantly more due to the new ROW required. Rejected

Options Considered to Maintain Reliability Option 6 - Create a 138-kV bus at TNP One and install a 600-MVA 345/138-kV autotransformer. Construct a new, approximately 4- mile 138-kV line from TNP One to Phillips substation. Rebuild the Phillips to Robertson 138-kV line to have a Rate B of 422 MVA. Reconductor Gibbons Creek to Greens Prairie 138-kV line to have a Rate B of 386 MVA. Rebuild Robertson to Hearne 138-kV line to have a Rate B of 422 MVA. Complete the Booneville to College Station Switch 138-kV upgrade. Convert Booneville to Tabor to 138-kV operation. Complete the Hearne to Tabor 138-kV upgrade. This option did not provide the long term reliability benefits that the selected option did. Also, at a cost of $27,688,400 it cost more than the selected option and did not provide additional production cost savings. Rejected

Options Considered to Maintain Reliability Option 7 - Create a 345-kV bus at Greens Prairie and build a new, approximately 13-mile 345-kV line from Gibbons Creek to Greens Prairie. Install an autotransformer with a Rate B of at least 600 MVA at Greens Prairie. When the above upgrade was added it induced other overloads which would require a significant amount of lines to be rebuilt. Because of this it would cost more than the selected option with no additional reliability or production cost benefits. Not Viable

Options Considered to Maintain Reliability Option 8 - Create a 345-kV bus at Dansby and loop one of the existing 345-kV lines from Gibbons Creek to Twin Oak into Dansby. This would consist of constructing approximately 20 miles of new double circuit 345-kV line on new ROW and the installation of a 600-MVA 345/138-kV autotransformer at Dansby. Complete the Booneville to College Station Switch 138-kV upgrade. Convert Booneville to Tabor to 138-kV operation. Move the 69-kV line from Sutton to terminate at Tabor. At a cost of $32,300,000 this options cost more than the selected option and did not provide any additional production cost savings. Rejected

Options Considered to Maintain Reliability Option 9 - Install a 100-MW DC tie between ERCOT and SERC at College Station Switch or purchase the SERC line currently owned by Entergy which runs from near College Station Switch to the Tenaska Frontier power plant. This option did not solve all of the reliability needs for the area. Since it would require additional upgrades and because either the DC tie or purchasing the SERC line would involve complexities on various levels, this option was not considered further. Not Viable